A method of drilling a borehole from a surface location with a drill string, and a system for implementing the method are provided. The method includes a rotary mode that involves rotating the drill string at a rotary mode rotation rate in order to drill the borehole for a rotary interval, an orientation mode that involves rotating the drill string at an orientation mode rotation rate and transitioning the rotation of the drill string from the orientation mode rotation rate to a surface stop orientation, and maintaining the drill string at a surface fixed orientation in order to drill the borehole in a directional mode for a directional interval. The surface stop orientation is selected based upon a predicted relationship between the surface stop orientation and a toolface stop orientation.

A method device, and system is described herein for pushing a rotary drill bit. Pushing the rotary drill bit ears include receiving a target direction in a formation to push the rotary drill bit wile drilling a wellbore in a formation. Pushing the rotary drill bit can also include opening, at a first rotational position of a rotary bit pushing device disposed proximate to the rotary drill bit within the wellborn, a first inlet port of a first flow regulator. Pushing the rotary drill bit can further include closing, after the first rotational position of the rotary bit pushing device the first inlet port. Pushing the rotary drill bit can also include sending, to a second flow regulator of the rotary bit pushing device, a second quantity of drilling fluid.

A method device, and system is described herein for pushing a rotary drill bit. Pushing the rotary drill bit ears include receiving a target direction in a formation to push the rotary drill bit wile drilling a wellbore in a formation. Pushing the rotary drill bit can also include opening, at a first rotational position of a rotary bit pushing device disposed proximate to the rotary drill bit within the wellborn, a first inlet port of a first flow regulator. Pushing the rotary drill bit can further include closing, after the first rotational position of the rotary bit pushing device the first inlet port. Pushing the rotary drill bit can also include sending, to a second flow regulator of the rotary bit pushing device, a second quantity of drilling fluid.

A steerable earth boring assembly which includes an annular collar and a drive shaft with a drill bit, where the shaft pivots with respect to the collar. An upper portion of the shaft inserts into an orientation sleeve which resides in the collar. An axial bore is obliquely formed through the orientation sleeve, and in which the upper portion inserts. An angular offset between the drive shaft and collar is changed by adjusting azimuthal positions of the orientation sleeve with respect to the collar. A brake assembly is included for applying a restraining force onto the orientation sleeve.

System and methods for monitoring casing wear for a well during a drilling operation are provided. Casing design parameters for a planned well are determined during a planning phase of the drilling operation. A wear factor along a length of the planned well is computed based on the casing design parameters. A casing wear map is generated based on the computed wear factor along the length of the planned well relative to one or more of the casing design parameters. The generated casing wear map is visualized via a display of a computing device. The visualized casing wear map enables a user of the computing device to estimate casing wear for the planned well and determine an appropriate casing design for the planned well based on the estimated casing wear.

A tool for drilling subterranean formations includes a tool body having a face surface, a blade extending radially outward on the face surface toward a gage surface, and a plurality of cutting structures disposed in the blade. Each of the plurality of cutting structures comprises a substantially spherical body of particulate impregnated matrix material. A method of forming the tool includes forming a tool body having the plurality of cutting structures dispersed therein. A method of using the tool includes rotating the earth-boring tool within a wellbore and engaging a formation material of an earth formation with an outer surface of the blade and wearing the outer surface of the blade to expose the spherical cutting structure. After wearing the outer surface of the blade, the method includes engaging the earth formation with the spherical cutting structure.

A downhole vibratory tool for placement in drillstrings which creates vibration in the drillstring while drilling. A rotary drive rotates in response to fluid flow through it, rotating a rotor having a lower end engaging an upper end of a mandrel. The mandrel is held in a main body such that it is rotationally locked with respect to the main body, but can move longitudinally within a restricted range. The lower end of the rotor and the upper end of the mandrel have interfacing surfaces. Rotation of the rotor and interaction of the interfacing surfaces creates a back-and-forth movement of the mandrel with respect to the rest of the tool, creating the desired vibratory motion.

A downhole vibratory tool for placement in drillstrings which creates vibration in the drillstring while drilling. A rotary drive rotates in response to fluid flow through it, rotating a rotor having a lower end engaging an upper end of a mandrel. The mandrel is held in a main body such that it is rotationally locked with respect to the main body, but can move longitudinally within a restricted range. The lower end of the rotor and the upper end of the mandrel have interfacing surfaces. Rotation of the rotor and interaction of the interfacing surfaces creates a back-and-forth movement of the mandrel with respect to the rest of the tool, creating the desired vibratory motion.

An example method for removal of stick-slip vibrations may comprise receiving a command directed to a controllable element of a drilling assembly. A smooth trajectory profile may be generated based, at least in part, on the command. A frictional torque value for a drill bit of the drilling assembly may be determined. The example method may further include generating a control signal based, at least in part, on the trajectory profile, the frictional torque value, and a model of the drilling assembly, and transmitting the control signal to the controllable element.

A downhole adjustable drilling inclination tool including an outer housing, an inner housing, a compression spring, a piston assembly, and a tilt housing. The piston assembly is fluidly controlled to move axially along the outer diameter of a bottom end portion of the inner housing so that a rotatable control ring moves about a guide pin to hold a neutral, straight, or bent position of the piston assembly corresponding to an amount of compression of the compression spring. The tilt housing partially disposed within the outer housing includes a bolt plate pin channel configured to receive a bolt plate pin of the piston assembly that travels to tilt the tilt housing by a tilting mechanism that connects the tilt housing to the outer housing and position the tilt housing in a neutral, straight, or bent position corresponding to the neutral, straight, or bent position of the piston assembly.